US11008838B2 - Switchable crossover tool with hydraulic transmission - Google Patents
Switchable crossover tool with hydraulic transmission Download PDFInfo
- Publication number
- US11008838B2 US11008838B2 US16/308,230 US201616308230A US11008838B2 US 11008838 B2 US11008838 B2 US 11008838B2 US 201616308230 A US201616308230 A US 201616308230A US 11008838 B2 US11008838 B2 US 11008838B2
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- tool
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- uphole
- downhole
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- 239000012530 fluid Substances 0.000 claims abstract description 47
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- 239000004568 cement Substances 0.000 claims description 27
- 230000004913 activation Effects 0.000 claims description 16
- 230000015572 biosynthetic process Effects 0.000 claims description 9
- 230000009849 deactivation Effects 0.000 claims description 5
- 239000000463 material Substances 0.000 description 11
- 230000008878 coupling Effects 0.000 description 8
- 238000010168 coupling process Methods 0.000 description 8
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- 238000005553 drilling Methods 0.000 description 7
- 238000005755 formation reaction Methods 0.000 description 7
- 239000000203 mixture Substances 0.000 description 6
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- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
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- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- 239000011398 Portland cement Substances 0.000 description 1
- XUIMIQQOPSSXEZ-UHFFFAOYSA-N Silicon Chemical compound [Si] XUIMIQQOPSSXEZ-UHFFFAOYSA-N 0.000 description 1
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Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/04—Gravelling of wells
- E21B43/045—Crossover tools
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
- E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
- E21B34/102—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/06—Sleeve valves
Definitions
- a cement composition is disposed between the walls of the wellbore and the exterior of a pipe string, such as a casing string, that is positioned within the wellbore.
- the cement composition is permitted to set in the annulus thereby forming an annular sheath of hardened, substantially impermeable cement therein.
- the cement sheath physically supports and positions the pipe in the wellbore and bonds the pipe to the walls of the wellbore whereby the migration of fluids between zones or formations penetrated by the wellbore is prevented.
- a conventional method of cementing involves pumping the cement composition down through the casing and then up through the annulus.
- the volume of cement required to fill the annulus must be calculated.
- a cement plug is placed in the casing.
- a drilling mud is then pumped behind the cement plug such that the cement is forced into and up the annulus from the far end of the casing string to the surface or other desired depth.
- the cement plug reaches a landing collar, float collar, or float shoe disposed proximate the far end of the casing, the cement should have filled the entire volume of the annulus. At this point, the cement is allowed to cure in the annulus into the hard, substantially impermeable mass.
- Reverse cementing is an alternative cementing method in which the cement composition is pumped directly into the annulus between the casing string and the wellbore. Using this approach, the pressure required to pump the cement to the far end of the annulus is much lower than that required in conventional cementing operations.
- Liner casing does not extend all the way to the wellhead. Rather, liner casing is typically suspended from the bottom of an upper casing segment, requiring a liner hanger.
- reverse cementing of the liner casing can require crossover cementing, in which cement is delivered downhole through a conveyance such as a drill pipe, and then crossed over into the annulus between the liner casing and the wellbore.
- FIG. 1 depicts a well system with liner casing undergoing reverse circulation cementing using a cross-over tool in a reverse circulation mode, in accordance with one or more embodiments;
- FIG. 2 depicts the well system with the cross-over tool in a conventional circulation mode, in accordance with one or more embodiments
- FIG. 3 depicts a cross-over tool an initial run-in state, in accordance with one or more embodiments
- FIG. 4 depicts a cross-sectional view of a tool body of the cross-over tool, in accordance with one or more embodiments
- FIG. 5 depicts a side view of a flow sleeve of the cross-over tool, in accordance with one or more embodiments
- FIG. 6 depicts a cross-sectional view of a transmission sleeve of the cross-over tool, in accordance with one or more embodiments
- FIG. 7 depicts the cross-over tool in a conventional circulation mode with an external packer actuated, in accordance with one or more embodiments
- FIG. 8 depicts the flow path through the cross-over tool during the conventional circulation mode, in accordance with one or more embodiments
- FIG. 9 depicts the cross-over tool in a reverse circulation mode, in accordance with one or more embodiments.
- FIG. 10 depicts converting the cross-over tool back into conventional circulation mode, in accordance with one or more embodiments
- FIG. 11 depicts the cross-over tool having been switching between conventional circulation and reverse circulation twice, in accordance with one or more embodiments
- FIG. 12 depicts a hanger activation ball traveling through the cross-over tool, in accordance with one or more embodiments.
- FIG. 13 depicts elements of the crossover tool that facilitate pulling the crossover tool out of hole, in accordance with one or more embodiments.
- the present disclosure provides a cross-over tool for enabling reverse circulation cementing in a well with liner casing.
- the cross-over tool is switchable between conventional circulation and reverse circulation as needed to accommodate different stages of the cementing operation.
- the present systems and techniques are also applicable to other fluid circulation operations and not limited to cementing.
- the present disclosure uses a cementing operation to illustrate an application of the crossover tool, the cross-over tool can also be used in a variety of other operations in which a material is to be placed downhole or used to displace another material.
- FIG. 1 depicts a well system 100 with liner casing 132 undergoing reverse circulation using a crossover tool 128 , in accordance with one or more embodiments.
- the system 100 includes a rig 102 centered over a subterranean oil or gas formation 104 located below the earth's surface 106 .
- a wellbore 108 extends through the various earth strata including the formation 104 .
- An upper casing string 110 is located in the wellbore 108 and an annulus 112 is formed between the upper casing string 110 and the wellbore 108 .
- the rig 102 includes a work deck 118 that supports a derrick 120 .
- the derrick 120 supports a hoisting apparatus 122 for raising and lowering pipe strings such as the upper casing string 110 .
- a pump 116 may be located on the work deck 118 and is capable of pumping a variety of fluids, such as cementing material, into the well.
- the pump 116 may include a pressure sensing means that provides a reading of back pressure at the pump discharge.
- a liner casing 132 is suspended within the wellbore 108 extending further downhole from the upper casing string 110 .
- the liner casing 132 is coupled to a liner hanger 130 , which is coupled to the crossover tool 128 .
- the liner casing 132 , the liner hanger 130 , and the crossover tool 128 are all suspended from a pipe 114 , such as drill pipe, which extends to the surface 106 .
- the liner casing 132 and/or liner hanger 130 may be set to the upper casing string 110 and is at least partially suspended by the upper casing string 110 .
- the crossover tool 128 is configured to separate and direct downhole and uphole flow. Specifically, the crossover tool 128 is switchable between enabling reverse circulation and enabling conventional circulation flow through the wellbore 108 .
- the upper casing string 110 is cemented prior to cementing the liner casing 132 , through conventional or reverse cementing techniques.
- the wellbore is drilled deeper after cementing the upper casing string 110 .
- the liner casing 132 is then positioned in the additionally formed well depth and cemented via reverse cementing.
- FIG. 1 illustrates the crossover tool 128 in a reverse circulation mode. As illustrated in FIG. 1 , during a reverse cementing operation for cementing liner casing 132 , a cementing material is pumped, via the pump 116 located at the surface 106 , into the pipe 114 . The cementing material travels downhole through the pipe 114 into the crossover tool 128 .
- the cementing material is then directed out of the crossover tool 128 and continues downhole, filling a lower annulus 134 between the liner casing 132 and the wellbore 108 towards well bottom 126 , thereby cementing the annulus 134 .
- the fluid return path is uphole through the inside of the liner casing 132 , through the liner hanger 130 and into the crossover tool 128 .
- the crossover tool 128 directs the uphole flow into an upper annulus 136 between the pipe 114 and the upper casing string 110 and to the surface 106 .
- the upper annulus 136 between the pipe 114 and the upper casing string 110 is separated from the annulus 134 between the liner casing 132 and the wellbore 108 by the crossover tool 128 .
- the crossover tool 128 provides an internal downhole flow path that couples the pipe 114 and the annulus 134 between the liner casing 132 and the wellbore 108 .
- the crossover tool 128 further provides a separate internal uphole flow path that couples the inside of the liner casing 132 and the upper annulus 136 between the pipe 114 and the upper casing string 110 .
- the crossover tool 128 is switchable between a reverse circulation mode, as illustrated in FIG. 1 , and a conventional circulation mode, as illustrated in FIG. 2 .
- a reverse circulation mode as illustrated in FIG. 1
- a conventional circulation mode as illustrated in FIG. 2 .
- downhole flow is directed downhole through the pipe 114 and through the inside of the liner casing 132 towards well bottom 126 , at which point flow is directed uphole through the annulus 134 between the liner casing 132 and the wellbore 108 and further uphole through the annulus between the upper casing string 110 and the pipe 114 to the surface 106 .
- the wellbore 108 is typically filled with various fluids such as drilling fluid which may be displaced uphole through the uphole return path. Drilling fluid has a different density profile than cementing material.
- drilling fluid typically has a lower density than cementing material.
- Drilling fluid may be any typical drilling fluid such as a water-based or oil-based drilling fluid.
- the cementing material used may be or include any typical hydraulic cementitious material that includes calcium, aluminum, silicon, oxygen, sulfur, and/or any mixture thereof and can set and harden by reaction with water.
- Exemplary hydraulic cementitious materials may be or include, but are not limited to, one or more Portland cements, one or more pozzolana cements, one or more gypsum cements, one or more alumina cements (e.g., high aluminum content cement), one or more silica cements, one or more high alkalinity cements (e.g., pH of about 12 to about 14), one or more resins, or any mixture thereof.
- one or more resins may be used in place of cement or in combination with cement.
- FIG. 3 illustrates a cross-over tool 300 , such as can be used as the cross-over tool 128 , in an initial run-in state.
- the tool 300 is run downhole into the upper casing string 110 in such a state.
- the tool 300 includes a body 302 having an uphole end 308 and a downhole end 310 .
- the uphole end 308 may be coupled to a conveyance such as pipe 114 ( FIG. 1 ).
- the downhole end 310 may be coupled to liner casing 132 via a liner hanger 130 ( FIG. 1 ).
- the tool body 302 defines a main tool path 306 through the cross-over tool 300 .
- the cross-over tool 300 also includes an external packer 304 located on the outside of the cross-over tool 300 and within the upper casing string 110 .
- the external packer 304 is in an unactuated position when the cross-over tool 300 is in the initial run-in state illustrated in FIG. 3 , in which a packer sleeve 304 a is disengaged from a packer body 304 b , leaving a space between the packer 304 and the upper casing string 110 permitting fluid flow therethrough.
- the packer 304 is mechanically coupled to a packer slider 316 located within the main tool path 306 and retained within one or more slots 318 such that moving the packer slider 316 along the slots 318 actuates the packer 304 to form a seal between the cross-over tool 300 and the upper casing string 110 .
- the tool body 302 further includes a flow sleeve chamber 320 a , a coupling chamber 320 b , and a transmission sleeve chamber 320 c .
- a flow sleeve 312 is located within the flow sleeve chamber 320 a and is movable along its length, in which the flow sleeve chamber 320 a forms an auxiliary chamber with the flow sleeve 312 .
- a transmission sleeve 314 is located within the transmission sleeve chamber 320 c and movable along its length.
- the coupling chamber 320 b hydraulically couples the first and coupling chamber segments 320 a , 320 c .
- the coupling chamber 320 b , as well as portions of the first and transmission sleeve chambers 320 a , 320 c between the flow sleeve 312 and the transmission sleeve 314 are filled with fluid and in fluid communication, forming a hydraulic pressure transmission therebetween.
- the first and transmission sleeve chambers 320 a , 320 c are positioned in opposing directions such that shifting one sleeve results in shifting the other sleeve in the opposite direction via fluid transmission.
- the flow sleeve 312 is movable with respect to the tool body 302 to switch the cross-over device 300 between the conventional circulation mode and the reverse circulation mode.
- the flow sleeve 312 is mechanically coupled to and movable via a flow sleeve slider 322 located within the main tool path 306 .
- the transmission sleeve 314 is mechanically coupled to and movable via a transmission sleeve slider 324 also located within the main tool path 306 .
- FIG. 4 depicts a cross-sectional view of the tool body 302 alone, in accordance with one or more embodiments.
- the tool body 302 includes an inner wall 402 and an outer wall 404 .
- the inner wall 402 defines the main tool path 306 through the switchable cross-over device 300 .
- the transmission chamber 320 is formed between the outer wall 404 and inner wall 402 .
- the tool body 302 further includes one or more uphole annulus ports 412 and one or more downhole annulus ports 414 formed in the outer wall 404 , and one or more uphole tool ports 416 and one or more downhole tool ports 418 formed in the inner wall 402 .
- the ports 412 , 414 in the outer wall 404 open to outside of the tool body 302 , such as into annulus 134 or 136 and the ports 416 , 418 in the inner wall 402 open to the main tool path 306 .
- the tool body 302 further includes a flow sleeve slot 420 to facilitate coupling of the flow sleeve 312 to the flow sleeve slider 322 and to provide a guide for sliding the flow sleeve 312 .
- the tool body 302 similarly includes a transmission sleeve slot 422 to facilitate coupling of the transmission sleeve 314 to the transmission sleeve slider 324 and to provide a guide for sliding the transmission sleeve 314 .
- the tool housing 302 further includes a coupling feature 426 located at an uphole end of the flow sleeve chamber 320 a configured to retain the flow sleeve 312 until the flow sleeve 312 is pulled downward.
- FIG. 5 illustrates a side view of the flow sleeve 312 , in accordance with one or more embodiments.
- the flow sleeve 312 includes an open portion 502 and a segmented portion 504 .
- Raised barriers 512 isolate the open portion 502 from the segmented portion 504 when located within the flow sleeve chamber 320 a .
- the segmented portion 504 is further partitioned into compartments 506 by raised barriers 514 which isolate the compartments 506 when located within the flow sleeve chamber 320 a , thereby separating the flow sleeve chamber 320 a into at least a first auxiliary path and a second auxiliary path.
- At least one of the compartments 506 includes an uphole port 508 and at least one of the compartments 506 includes a downhole port 510 .
- the flow sleeve 312 further includes a latching end 514 configured to latch onto the coupling feature 426 of the tool body 302 .
- FIG. 6 illustrates a cross-sectional view of the transmission sleeve 314 , in accordance with one or more embodiments.
- the transmission sleeve 314 includes a body 602 and a raised barrier 604 that receives and applies hydraulic force.
- the transmission sleeve also includes the slider 324 , which extends into the main tool path 306 of the tool body 302 when assembled.
- FIG. 7 illustrates the cross-over tool 300 in a conventional circulation mode with the external packer 304 actuated.
- the packer 304 expands to form a seal between the cross-over tool 300 and the upper casing string 110 , thereby separating annulus 136 from annulus 134 .
- the packer 304 is set by pulling the packer sleeve 304 a downward into the packer body 304 b to expand the packer body 304 b .
- the packer sleeve 304 is mechanically coupled to the packer slider 316 such that when the packer slider 316 is moved towards the downhole end 310 , the packer sleeve 304 b is pulled downward as well, setting the packer 304 .
- a different type of packer may be used to separate annulus 136 from annulus 134 .
- the packer slider 316 is located within the main tool path 306 and moved downward by a packer dart 330 containing a shear ring 332 travelling to downhole from the downhole end 310 of the body 302 through the main tool path 306 .
- the packer slider 316 includes a biasing element such as a surface or protrusion such that the packer dart 330 catches the biasing element as it travels downhole, thereby pulling the slider 316 downward.
- a pressure is applied to the packer dart from the surface to push it downhole and to move packer dart 330 .
- the packer dart 330 includes a sealing feature (not shown) which seals against the main tool path 306 , enabling the pressure differential needed for the packer dart 330 to push the slider 316 downward and set the packer 304 .
- the packer dart 330 may also include an abutment feature (not shown) for catching and pulling the packer dart 330 downhole. The packer dart 330 is removed by increasing the pressure uphole of the packer dart 330 which pushes the packer dart 330 downhole, ejecting it from the main tool path 306 .
- the increased pressure causes the packer dart 330 to separate from the abutment feature, so that the packer dart 330 is ejected from the main tool path 306 , leaving the abutment feature behind.
- the abutment feature includes an orifice such that fluid can still flow through the main tool path 306 .
- the main tool path 306 is open.
- FIG. 8 illustrates the flow path through the cross-over tool 300 during conventional circulation mode.
- the flow sleeve 312 is positioned at the uphole end of the flow sleeve chamber 320 a such that the uphole annulus ports 412 and downhole annulus ports 414 of the outer wall 404 of the tool body 302 are aligned and/or coupled to the open portion 502 of the flow sleeve 312 .
- Arrows 802 indicate the downhole flow path, from the surface to well bottom.
- Arrows 804 indicate the uphole flow path of returning fluid from well bottom to surface.
- Downhole flow 802 travels through the main tool path 306 .
- Uphole flow 804 travels up the lower annulus 134 , into the cross-over tool 300 via the downhole annulus port 414 of the outer wall 404 of the tool body 302 , and out of the cross-over tool 300 into the upper annulus 136 via the uphole annulus port 412 of the outer wall 404 of the tool body 302 .
- the cross-over tool 300 provides an auxiliary path for return fluid to flow up the annulus 134 , 136 , bypassing the packer 304 .
- FIG. 9 illustrates the cross-over tool 300 in a reverse circulation mode.
- an activation dart 902 is launched into the main tool path 306 .
- the activation dart 902 catches the flow sleeve slider 322 and pulls the flow sleeve slider 322 down, thereby pulling the flow sleeve 312 down to the downhole end of the flow sleeve chamber 320 a , such that the uphole and downhole ports of the outer wall 404 of the tool body 302 are aligned and/or coupled to the partitioned portion 504 of the flow sleeve 312 .
- the activation dart 902 stops when the flow sleeve slider 322 reaches the end of the flow sleeve slot 420 and remains within the main tool path 306 .
- the activation dart 902 also includes seals 904 which seal the main tool path 306 while the dart 902 is positioned therein.
- the main tool path 306 is separated into the upper tool path 306 a and lower tool path 306 b by the dart 902 and the uphole end 308 separated from the downhole end 310 .
- the uphole ports 508 of the flow sleeve 312 and the uphole annulus ports 412 , 416 of the tool body 302 are uphole of the dart 902 .
- the downhole ports 510 of the flow sleeve 312 and the downhole annulus ports 414 , 418 of the tool body 302 are downhole of the dart 902 .
- hydraulic pressure moves the transmission sleeve 314 towards the uphole end of the transmission sleeve chamber 320 c , as shown in FIG. 9 .
- the transmission sleeve slider 324 is moved to the upper end of the transmission sleeve slider slot 422 .
- the uphole ports 508 of the flow sleeve are aligned with the uphole tool ports 416 of the inner wall 402 of the tool body 302 and the downhole ports 510 of the flow sleeve 312 are aligned with the downhole tool ports 418 of inner wall 402 of the tool body 302 .
- the uphole ports 508 are in formed in compartments isolated from the downhole ports 510 when the sleeve is located in the tool body 302 . Thus, flow through the uphole ports 508 is isolated from flow through the downhole ports 510 .
- arrows 906 indicate the downhole flow path during reverse circulation
- arrows 908 indicate the uphole flow path of returning fluid during reverse circulation.
- Downhole flow travels through the upper tool path 306 a until the dart 902 .
- Flow is then directed into the uphole tool ports 416 of the inner wall 402 of the tool body 302 and into the uphole port 508 of the flow sleeve 312 , through the respective compartments 506 , and out into the lower annulus 134 through the downhole annulus port 414 of the outer wall 404 of the tool body 302 , thus enabling reverse circulation.
- the uphole flow path of returning fluid goes towards the surface through the lower tool path 306 b until flow reaches the dart 906 .
- Flow is then directed into the downhole tool port 418 of the inner wall 402 of the tool body 302 and into the downhole ports 510 of the flow sleeve 312 , through the respective compartments 506 , and out into the upper annulus 136 through the uphole annulus ports 412 of the outer wall 404 of the tool body 302 .
- the downhole flow path is kept isolated from the uphole flow path.
- FIG. 10 illustrates putting the cross-over tool 300 back into conventional circulation mode.
- a deactivation dart 1002 is launched into the main tool path 306 to push the activation dart 902 past the flow sleeve slider 322 .
- Either the activation dart 902 or the deactivation dart 1002 then catches the transmission sleeve slider 324 and pushes the slider 324 to the lower position. Respectively, this moves the transmission sleeve 314 downward as well, applying a hydraulic pressure onto the flow sleeve 312 , and thereby pushing the flow sleeve 312 upward to the upper end of the flow sleeve chamber 320 a and into the conventional circulation position, as illustrated in FIG. 10 .
- the activation dart 902 shears off from a first shear ring 1004 as it is pushed past the flow sleeve slider 322 , leaving the shear ring behind on the flow sleeve slider 322 . In one or more embodiments, the activation dart 902 then catches the transmission sleeve slider 324 via a second shear ring 1006 having a smaller diameter than the first shear ring 1004 , and pushes the transmission sleeve slide 324 into the lower position.
- the activation dart 902 drops out of the cross-over tool 300 after passing the flow sleeve slider 324 , and the deactivation dart 1002 catches and pushes the transmission sleeve slider 324 . After the transmission sleeve slider 324 is pushed down, and the sleeves 312 , 314 are in the conventional circulation positions. Pressure uphole of the darts 1002 , 902 may be increased to push both darts 1002 , 902 out of the main tool path 306 . In one or more embodiments, the activation dart 902 shears from the second shear ring 1006 , dropping out of the cross-over tool 300 and leaving behind the second shear ring 1006 on the slider 324 .
- the cross-over tool 300 is put back into conventional circulation mode, in which fluid is delivered downhole through the main tool path 306 and returns uphole through the annulus 134 , 136 , utilizing the cross-over tool as an auxiliary path to bypass the packer 304 , as illustrated in FIG. 8 .
- FIGS. 9 and 10 can be repeated to switch the cross-over tool 300 between the conventional circulation mode and the reverse circulation mode.
- a first shear ring 1004 from an activation dart 902 is added to the flow sleeve slider 322 .
- a second shear ring 1006 is added to the transmission sleeve slider 324 .
- the number of switches permitted during one run of the tool 300 may be limited by the number of shear rings that can be added to either slider.
- FIG. 11 illustrates two first shear rings 1004 on the flow sleeve slider 322 and two second shear rings 1006 on the transmission sleeve slider 324 , indicating that the cross-over tool has been switch from the conventional circulation to reverse circulation and back twice.
- the liner hanger 130 coupled downhole of the cross-over tool 300 may need to be activated after the liner 132 is cemented.
- a ball drop is required to activate the liner hanger 130 .
- FIG. 12 illustrates such a ball 1202 travelling through the main tool path 306 cross-over tool 300 .
- the ball 1202 travels past the shear rings 1006 and through the cross-over tool 300 into the liner hanger 130 .
- the shear rings 1006 may be expandable to accommodate the ball 1202 .
- FIG. 13 illustrates elements of the crossover tool 300 that facilitate pulling the crossover tool 300 out of hole.
- the packer sleeve 304 a When pulling out of hole, the packer sleeve 304 a is coupled to the tool body 302 via a saw tooth element 1302 and pulled uphole with the tool body 302 .
- the packer body 304 b may retain on the casing wall 110 due to frictional force between the packer body 304 b and the casing 110 .
- a block ring 1304 shears from the tool body 302 and the packer sleeve 304 a is lifted out of the packer body 304 b .
- the packer body 304 b can then collapse and move with respect to the casing 110 .
- the packer body 304 b and block ring 1304 are then caught by a stopper 1306 on a lower portion of the tool body 302 and lifted uphole with the tool body 302 , thereby pulling all crossover tool 300 elements out of hole.
- embodiments of the present disclosure further relate to one or more of the following paragraphs:
- a switchable cross-over device for reverse cementing comprising: a tool body comprising: a main tool path separable into an uphole tool path and a downhole tool path; and an auxiliary chamber comprising an uphole annular port and a downhole annular port; and a flow sleeve located within the auxiliary chamber and movable between: a conventional circulation position, wherein the uphole tool path and the downhole tool path are in fluid communication, and the uphole annular port is in fluid communication with the downhole annular port through the auxiliary chamber; and a reverse circulation position, wherein the flow sleeve forms a first auxiliary flow path and a second auxiliary flow path in the auxiliary chamber, wherein the uphole tool path and the downhole annular port are in fluid communication via the first auxiliary flow path, and wherein the downhole tool path is in fluid communication with the uphole annular port.
- a switchable crossover system for reverse cementing a well extending through a subterranean formation comprising: a switchable crossover tool coupled between a conveyance and a casing segment located within a well, the switchable crossover tool comprising: a tool body comprising a main tool path and an auxiliary chamber; a annular packer located on the outside of the tool body separating an annulus between the switchable crossover tool and the well into an uphole annulus and a downhole annulus; and a flow sleeve located within the auxiliary chamber and movable between a conventional circulation mode and a reverse circulation mode; wherein in the conventional circulation mode, the conveyance is in fluid communication with the casing segment via the switchable crossover tool; and wherein in the reverse circulation mode, the conveyance is in fluid communication with the downhole annulus.
- a method of cementing a well wall extending through a subterranean formation comprising: setting a packer in an annulus between a cross-over tool and the well wall, wherein the packer separates the annulus into a downhole annulus and an uphole annulus; placing a plug within a main flow path of the cross-over tool, separating the main tool path into an uphole tool path and a downhole tool path; and moving a flow sleeve of the cross-over tool into a reverse circulation position, thereby placing the uphole tool path in fluid communication with the downhole annulus and placing the downhole tool path in fluid communication with the uphole annulus.
- axial and axially generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the central axis.
- a central axis e.g., central axis of a body or a port
- radial and radially generally mean perpendicular to the central axis.
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
- Multiple-Way Valves (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
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Abstract
Description
Claims (15)
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2016/053538 WO2018057010A1 (en) | 2016-09-23 | 2016-09-23 | Switchable crossover tool with hydraulic transmission |
Publications (2)
Publication Number | Publication Date |
---|---|
US20190178061A1 US20190178061A1 (en) | 2019-06-13 |
US11008838B2 true US11008838B2 (en) | 2021-05-18 |
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ID=61689711
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US16/308,230 Active 2037-05-10 US11008838B2 (en) | 2016-09-23 | 2016-09-23 | Switchable crossover tool with hydraulic transmission |
Country Status (7)
Country | Link |
---|---|
US (1) | US11008838B2 (en) |
AU (1) | AU2016423794B2 (en) |
CA (1) | CA3030626A1 (en) |
GB (1) | GB2567113B (en) |
NO (1) | NO20190240A1 (en) |
SG (1) | SG11201811153RA (en) |
WO (1) | WO2018057010A1 (en) |
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-
2016
- 2016-09-23 AU AU2016423794A patent/AU2016423794B2/en active Active
- 2016-09-23 GB GB1901870.4A patent/GB2567113B/en active Active
- 2016-09-23 CA CA3030626A patent/CA3030626A1/en not_active Abandoned
- 2016-09-23 US US16/308,230 patent/US11008838B2/en active Active
- 2016-09-23 SG SG11201811153RA patent/SG11201811153RA/en unknown
- 2016-09-23 WO PCT/US2016/053538 patent/WO2018057010A1/en active Application Filing
-
2019
- 2019-02-21 NO NO20190240A patent/NO20190240A1/en unknown
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Also Published As
Publication number | Publication date |
---|---|
CA3030626A1 (en) | 2018-03-29 |
SG11201811153RA (en) | 2019-01-30 |
GB2567113B (en) | 2021-08-04 |
GB2567113A (en) | 2019-04-03 |
GB201901870D0 (en) | 2019-04-03 |
WO2018057010A1 (en) | 2018-03-29 |
AU2016423794A1 (en) | 2019-01-03 |
US20190178061A1 (en) | 2019-06-13 |
AU2016423794B2 (en) | 2021-11-11 |
NO20190240A1 (en) | 2019-02-21 |
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